Fully-Funded 2020 Budget and Guidance
Bonterra's 2020 capital budget incorporates a measured approach to address the continued volatility in crude oil prices. The crude market for WTI pricing has dropped approximately 20 percent in the last month, with some signs it could accelerate further as the Coronavirus continues to spread. As active measures to contain the virus are implemented, it is anticipated that prices may respond accordingly with signs of recovery. There have been encouraging developments regarding the potential for additional pipeline capacity in
2020 Capital Budget
Bonterra's 2020 capital budget is designed to afford the Company greater flexibility around the execution of the capital program while prioritizing balance sheet protection, net debt reduction and the monthly amount of dividend payments. The planned budget structure will enable the Company to increase or decrease the level of spending on a monthly basis depending on the realized Canadian ("Edmonton Par") crude oil and natural gas pricing.
Bonterra intends to direct its 2020 budget to new wells primarily targeting the Cardium formation across the Company's Carnwood, Willesden Green and
2020 Capital Budget Objectives:
- Invest in higher rate-of-return, lower-risk light oil opportunities within the Company's extensive drilling inventory;
- Maintain an all-in (capital plus dividends and abandonments) payout ratio of less than 100 percent of funds flow;
- Direct the pace of the capital program to maintain spending flexibility throughout the year and effectively respond to a shifting price environment; and
- Maintain financial flexibility to achieve longer-term growth in production, reserves and funds flow per share while generating positive returns for shareholders.
Annual average production volumes are expected to range between 12,300 and 12,600 BOE per day. In the context of ongoing volatility in commodity prices, Bonterra will review on a monthly basis and may elect to adjust the amount and timing of capital spending to ensure sustainability and a payout ratio of less than 100 percent of funds flow.
Through continuous deployment of a single drilling rig, Bonterra's 2020 capital program forecasts the allocation of approximately
Based on the pricing and production assumptions for 2020 outlined below, Bonterra anticipates generating
Budget Summary
2020 Budget | |
Canadian Realized Oil Pricing per Bbl 1 | |
Average Daily Production (BOE per day) | 12,300 – 12,600 |
Oil and NGL weighting | 67% |
Funds Flow (millions) 2 | |
Capital Expenditures (millions) | |
Dividends (millions) | |
Free Funds Flow (millions) 1 |
Notes: | |
(1) | Canadian realized oil price is based on WTI US |
(2) | Funds Flow is estimated using the Canadian realized oil price above, a natural gas price of |
Bonterra will continue to regularly monitor changes to commodity prices and funds flow with the primary objective of directing funds flow to a prudent capital program, sustainable dividend and meaningful debt reduction. Bonterra's 2020 capital budget is designed to maximize Free Funds Flow in order to strengthen the balance sheet while returning capital to shareholders in the form of dividends1. The Company may elect to adjust the amount and timing of capital spending to ensure optimal returns while seeking to further reduce its debt levels. A commitment to sustainability and debt reduction will remain intact through 2020.
2019 Operational Highlights
During 2019, Bonterra invested approximately
During 2019, Bonterra generated Free Funds Flow1 of
(1) | "Free Funds Flow" and "Capital and Dividend Payout Ratio" do not have standardized meanings. See "Cautionary Statements" below. |
(2) | All 2019 financial amounts are unaudited. See advisories. |
(3) | Comprised of 67% light oil and natural gas liquids and 33% conventional natural gas. |
2019 Corporate Reserves Information
The following summarizes certain information contained in the Sproule Report. The Sproule Report was prepared in accordance with the definitions, standards and procedures contained in the Canadian Oil and Gas Evaluation Handbook ("COGE Handbook") and National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). Additional reserves information as required under NI 51-101 will be included in the Company's Annual Information Form which will be filed on SEDAR on or by
Reserve Report Highlights
- Total proved reserves increased by 0.9 million BOE to 81.5 million BOE (67 percent oil and liquids), while total proved plus probable ("P+P") reserves were maintained at 101.1 million BOE (67 percent oil and liquids).
- Total proved reserves per fully diluted share totaled 2.44 BOE, a 1.0 percent increase over 2.42 BOE in 2018, while P+P reserves per fully diluted share totaled 3.03 BOE compared to 3.04 BOE per share in 2018.
- Growth in total proved reserves before production of 5.4 million BOE resulted in production replacement of 120 percent.
- Total proved reserves represent 81 percent of total P+P reserves, compared to 80 percent in 2018, exemplifying the low-risk nature of Bonterra's asset base.
- Net present value of future net revenue discounted at 10 percent (before tax) ("NPV10 BT") for P+P reserves totaled
$1.2 billion , while total proved reserves totaled$961.9 million and proved developed producing ("PDP") reserves totaled$586.4 million . The Company's PDP NPV10 BT was 38 percent higher than Bonterra's year end 2019 enterprise value (market capitalization plus net debt of$292.8 million ). - Generated finding and development ("F&D")4,5 recycle ratios4,5 of 1.85 times on a total proved basis and 1.45 times on a P+P basis, calculated based on the Company's estimated annual average field netback4,5 of
$26.45 per BOE (unaudited) divided by the F&D costs4,5 (including future development capital ("FDC"). - Increased P+P, TP, and PDP reserve life indices ("RLI")5 to approximately 23 years on a P+P basis, 19 years on a total proved basis, and nine years on a PDP basis (based on 2019 average production of 12,305 BOE per day), supporting Bonterra's ability to continue drilling and developing its attractive, Cardium oil focused asset base.
(4) | All 2019 financial amounts are unaudited. See advisories. |
(5) | "Finding and Development costs" or "F&D costs", "recycle ratio", "operating netback" and "reserve life index" do not have standardized meanings. See the table "Capital Program Efficiency" and "Information Regarding Disclosure on Oil and Gas Reserves and Operational Information" contained in this news release. |
Summary of Gross Oil and Gas Reserves as of
Light and | Natural Gas | Natural Gas | Oil | Future | |||
(MBbl) | (MMcf) | (MMcf) | (MBbl) | (MBoe) | ($000s) | ||
Proved | |||||||
Developed Producing | 22,227 | 69,928 | 5,616 | 3,319 | 38,136 | 76 | |
Developed Non-producing | 591 | 1,177 | 42 | 55 | 849 | 1,374 | |
Undeveloped | 23,891 | 72,637 | 12,945 | 4,398 | 42,552 | 638,193 | |
Total Proved | 46,709 | 143,742 | 18,603 | 7,771 | 81,537 | 639,643 | |
Total Probable | 11,165 | 34,109 | 4,872 | 1,878 | 19,540 | 12,006 | |
Total P+P 1,2,3 | 57,874 | 177,851 | 23,475 | 9,649 | 101,077 | 651,650 | |
Notes: | |
(1) | Reserves have been presented on gross basis which are the Company's total working interest share before the deduction of any royalties and without including any royalty interests of the Company. |
(2) | Totals may not add due to rounding. |
(3) | Based on Sproule's |
(4) | Oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil. |
Reconciliation of Company Gross Reserves by Principal Product Type as of
Light & | Conventional Natural | Natural Gas | Oil Equivalent | |||||
Total | Proved + | Total | Proved + | Total | Proved + | Total | Proved + | |
(MBbl) | (MBbl) | (MMcf) | (MMcf) | (MBbl) | (MBbl) | (MBoe) | (MBoe) | |
Opening Balance, | 47,885 | 60,067 | 153,973 | 193,380 | 7,086 | 8,928 | 80,634 | 101,225 |
Extensions & Improved Recovery 2 | 2,551 | 3,154 | 9,348 | 11,543 | 664 | 817 | 4,773 | 5,894 |
Technical Revisions | (375) | (2,034) | 8,517 | 5,825 | 481 | 365 | 1,525 | (698) |
Discoveries | - | - | - | - | - | - | - | - |
Acquisitions | - | - | - | - | - | - | - | - |
Dispositions 3 | - | - | - | - | - | - | - | - |
Economic Factors | (685) | (645) | (714) | (643) | (100) | (101) | (904) | (853) |
Production | (2,668) | (2,668) | (8,779) | (8,779) | (360) | (360) | (4,491) | (4,491) |
Closing Balance, | 46,709 | 57,874 | 162,345 | 201,326 | 7,771 | 9,649 | 81,537 | 101,077 |
Notes: | |
(1) | Gross Reserves means the Company's working interest reserves before calculation of royalties, and before consideration of the Company's royalty interests. |
(2) | Increases to Extensions & Improved Recovery include infill drilling and are the result of step-out locations drilled by Bonterra and other operators on and near Company-owned lands. |
(3) | Includes volumes associated with Farm outs. |
(4) | Totals may not add due to rounding. |
Summary of Net Present Values of Future Net Revenue as of
($M) | Net Present Value Before Income Taxes Discounted at (% per Year) | |||
Reserves Category: | 0% | 5% | 10% | 15% |
Proved | ||||
Producing | 789,954 | 727,746 | 586,445 | 485,957 |
Non-producing | 17,432 | 13,466 | 10,627 | 8,593 |
Undeveloped | 981,038 | 578,193 | 364,808 | 241,291 |
Total proved | 1,788,424 | 1,319,405 | 961,880 | 735,842 |
Probable | 731,254 | 402,609 | 266,354 | 196,077 |
Total proved plus probable 1,2,3 | 2,519,678 | 1,722,014 | 1,228,235 | 931,919 |
Notes: | |
(1) | Evaluated by Sproule as at |
(2) | Net present values equal net present value before income taxes based on Sproule's forecast prices and costs as of |
(3) | Includes abandonment and reclamation costs as defined in NI 51-101. |
Commencing in 2019, Sproule began to include additional abandonment, decommissioning and reclamation obligations ("ADR") in the Company's reserves, resulting in a decrease of values compared to 2018. The Company previously reported certain Asset Restoration Obligations ("ARO") separately from those contained in the Company's
F&D Costs, Finding, Development & Acquisition ("FD&A") Costs and Recycle Ratio 7
Over the past three years, Bonterra has incurred the following FD&A3 and F&D3 costs both excluding and including FDC:
Total Proved Reserves Net Additions | P+P Reserves Net Additions | ||||||||||
2019 | 2018 | 2017 | 3 Yr Avg 5 | 2019 | 2018 | 2017 | 3 Yr Avg 5 | ||||
FD&A Costs per BOE 1,2,3,4,5 | |||||||||||
Including FDC | |||||||||||
Excluding FDC | |||||||||||
F&D Costs per BOE 1,2,3,4,5 | |||||||||||
Including FDC | |||||||||||
Excluding FDC | |||||||||||
Recycle Ratio 2,6 | |||||||||||
F&D (including FDC) | 1.9 | 2.1 | 1.7 | 1.9 | 1.5 | 1.9 | 2.0 | 1.8 | |||
Notes: | |
(1) | Barrels of oil equivalent may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 MCF: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. |
(2) | All 2019 financial amounts are unaudited. See advisories. |
(3) | The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development capital generally will not reflect total finding and development costs related to reserve additions for that year. |
(4) | The calculation of F&D and FD&A costs incorporates the change in FDC required to bring proved undeveloped and developed reserves into production. In all cases, the F&D or FD&A number is calculated by dividing the identified capital expenditures by the applicable reserves additions after changes in FDC costs. |
(5) | Three-year average is calculated using three-year total capital costs and reserve additions on both a total proved and P+P reserves on a weighted average basis. |
(6) | Recycle ratio is defined as field netback per BOE divided by F&D costs on a per boe basis. Field netback is a Non-IFRS Measure and calculated as revenue minus royalties, operating expenses and transportation expenses. Bonterra's operating netback in 2019, used in the above calculations, averaged |
(7) | "FD&A Cost", "F&D Cost", and "Recycle Ratio" do not have standardized meanings and therefore may not be comparable with the calculation of similar measures for other entities. See "Information Regarding Disclosure on Oil and Gas Reserves and Operational Information" in this news release. |
Cautionary Statements
This summarized news release should not be considered a suitable source of information for readers who are unfamiliar with
Use of Non-IFRS Financial Measures
Throughout this release the Company uses the terms "funds flow", "capital plus dividend payout ratio", "free funds flow" and "cash netback" to analyze operating performance, which are not standardized measures recognized under IFRS and do not have a standardized meaning prescribed by IFRS. These measures are commonly utilized in the oil and gas industry and are considered informative by management, shareholders and analysts. These measures may differ from those made by other companies and accordingly may not be comparable to such measures as reported by other companies.
The Company defines funds flow as funds provided by operations excluding effects of changes in non-cash working capital items and commissioning expenditures settled. Capital plus dividends payout ratio is calculated by dividing the sum of capital expenditures and cash dividends paid by funds flow. Free funds flow is defined as funds flow less dividends paid to shareholders, capital and decommissioning expenditures settled. We calculate cash netback by dividing various financial statement items as determined by IFRS by total production for the period on a barrel of oil equivalent basis.
Unaudited Financial Information
Certain financial and operating information included in this press release for the quarter and year ended
Information Regarding Disclosure on Oil and Gas Reserves and Operational Information
All amounts in this news release are stated in Canadian dollars unless otherwise specified. Bonterra's oil and gas reserves statement for the year ended
This press release contains metrics commonly used in the oil and natural gas industry, such as "recycle ratio", "finding and development costs", "finding and development recycle ratio", "finding, development and acquisition costs", and "operating netbacks". Each of these metrics are determined by Bonterra as specifically set forth in this news release. These terms do not have standardized meanings or standardized methods of calculation and therefore may not be comparable to similar measures presented by other companies, and therefore should not be used to make such comparisons. Such metrics have been included to provide readers with additional information to evaluate the Company's performance however, such metrics should not be unduly relied upon for investment or other purposes. Management uses these metrics for its own performance measurements and to provide readers with measures to compare Bonterra's performance over time.
Both F&D and FD&A costs take into account reserves revisions during the year on a per boe basis. The aggregate of the costs incurred in the financial year and changes during that year in estimated FDC may not reflect total F&D costs related to reserves additions for that year. Finding and development costs both including and excluding acquisitions and dispositions have been presented in this press release because acquisitions and dispositions can have a significant impact on Bonterra's ongoing reserves replacement costs and excluding these amounts could result in an inaccurate portrayal of its cost structure.
Management uses these oil and gas metrics for its own performance measurements and to provide shareholders with measures to compare Bonterra's performance over time, however, such measures are not reliable indicators of the Company's future performance and future performance may not compare to the performance in previous periods. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this press release, should not be relied upon for investment or other purposes.
Forward Looking Information
Certain statements contained in this release include statements which contain words such as "anticipate", "could", "should", "expect", "seek", "may", "intend", "likely", "will", "believe" and similar expressions, relating to matters that are not historical facts, and such statements of our beliefs, intentions and expectations about development, results and events which will or may occur in the future, constitute "forward-looking information" within the meaning of applicable Canadian securities legislation and are based on certain assumptions and analysis made by us derived from our experience and perceptions. Forward-looking information in this release includes, but is not limited to: expected cash provided by continuing operations; cash dividends; future ARO; future capital expenditures, including the amount and nature thereof; oil and natural gas prices and demand; expansion and other development trends of the oil and gas industry; business strategy and outlook; expansion and growth of our business and operations; and maintenance of existing customer, supplier and partner relationships; supply channels; accounting policies; credit risks; and other such matters.
All such forward-looking information is based on certain assumptions and analyses made by us in light of our experience and perception of historical trends, current conditions and expected future developments, as well as other factors we believe are appropriate in the circumstances. The risks, uncertainties, and assumptions are difficult to predict and may affect operations, and may include, without limitation: foreign exchange fluctuations; equipment and labour shortages and inflationary costs; general economic conditions; industry conditions; changes in applicable environmental, taxation and other laws and regulations as well as how such laws and regulations are interpreted and enforced; the ability of oil and natural gas companies to raise capital; the effect of weather conditions on operations and facilities; the existence of operating risks; volatility of oil and natural gas prices; oil and gas product supply and demand; risks inherent in the ability to generate sufficient cash flow from operations to meet current and future obligations; increased competition; stock market volatility; opportunities available to or pursued by us; and other factors, many of which are beyond our control.
Actual results, performance or achievements could differ materially from those expressed in, or implied by, this forward-looking information and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking information will transpire or occur, or if any of them do, what benefits will be derived there from. Except as required by law, Bonterra disclaims any intention or obligation to update or revise any forward-looking information, whether as a result of new information, future events or otherwise.
The forward-looking information contained herein is expressly qualified by this cautionary statement.
Frequently recurring terms
Bonterra uses the following frequently recurring terms in this press release: "WTI" refers to West Texas Intermediate, a grade of light sweet crude oil used as benchmark pricing in
Numerical Amounts
The reporting and the functional currency of the Company is the Canadian dollar.
The TSX does not accept responsibility for the accuracy of this release.
SOURCE
© Canada Newswire, source